1 cardinal surveys company bringing conformance within reach with proven technology. eliminate the...

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Cardinal Surveys Company

Bringing conformance within reach with proven technology.

Eliminate The Guesswork!

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Cardinal Surveys Company

Choose your treatment success rate:

0 - 5% Based on assumptions.

5 - 90% Based on partial data.

+90% Based on defined problems with solutions proven on previous applications.

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Assumptions

We know, it has to be this!

It’s the only thing that could cause that…

The model shows…

Probable Result:

Damage productive zones.

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Partial Data

Water Analysis - you know the zone, what’s the flow path?

Production History / Correlation - Flow path, parts is parts?

Bond Logs - Good until the first stimulation.

Injector Response - flow path, vertical fractures, offset wells...

Pump In Tracers without Production Logs - Path of least resistance, usually the good productive zone.

OR

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Call Wylie’s Psychic Logging Service

Cheap Rates

REAL CHEAP

Impress Your Boss

Don’t take the blame, we will!

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Step Rate Test

• Determine fracture point

• Reservoir protection

• Regulatory compliance

• Can’t be estimated or based on assumptions

• May be most vital of all diagnostics

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Step Rate Test

• Uniform Steps (Rates and Times)

• Down-hole, real-time pressure measurement

• Accurate flow rate measurment

• Recording and filtering of data

• Prepare well (shut in, water source)

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Define The Problem(Locate Production)

TRAC-III to determine conformance problem.

A. Annulus Logging with 7/8” O.D. Tools.

B. Flowing Wells

C. “Y” Tool & Submersible Pump (7/8” Tools).

D. Memory PLT (Horizontal Applications).

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Annulus TRAC-III Production Logging With 7/8” O.D. Tools

Tracer Velocities

Temperature Logs

Collar Locator

Gamma Ray

Capacitance

Pressure

Caliper

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Annulus Logging Candidates

4.5” Casing & 2.375” Tubing


Or any combination of larger casing and smaller tubing.

No liners or other restrictions in the annulus.

ROT: 100 BPD of produced fluids.

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Trac III Production Logs

• Dynamic, producing (e.g., actual or "real-time") conditions.

• Temperature log.• Capacitance log.• Radioactive tracer log.• All logs can be run simultaneously during one trip

in the well.• 5 1/2 inch casing and 2 7/8 inch tubing.• 4 1/2 inch casing and 2 3/8 inch tubing.

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• Positive monitoring of reservoir performance .• Detailed, zone-by-zone, information.• Changes in the down-hole conditions detected.• Reevaluate marginal production wells.• Rework watered-out or gassed-out wells.• Recompletion of unproductive offset wells.• Essential guidance for remedial-workover designs.• Cost-effective well recompletions.

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• Improved completion techniques for future wells. • Immediate verification of perforation efficiency .• Positive identification of the actual production

intervals.• Confirmation of open hole log analysis and

assumptions used in the initial completion.• Pinpoint mechanical problems.

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Document baseline production profile for future reference. Optimize pump placement. Discover unwanted water sources for remedial procedures. Correlate production results with injection profiles for

sweep efficiency of floods. Confirm engineering and geological assumptions and

analysis.

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Verify stimulation job effectiveness and techniques. Plan accurate placement of mechanical isolation tools

(bridge plugs and packers.) Locate thief zones and undesirable cross-flows. Real-time snap shot of production well.

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Rope Socket (15" - 5/8" fishing neck)

Capacitance Tool (40")

Caliper (69")

Collar Locator (28.5")

Scintillation Gamma Ray Detector (60")

Microprocessor Controlled Ejector (75.5")

Temperature Tool (37")

Memory Pressure Gauge (14”)

Total Tool Length with crossovers = 30’

7/8” O.D. Tool Lengths

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Annulus TRAC-III Preparation

•Pull Tubing

•Remove Anchor

•Set Pump 100’ above Perfs

•Dual Completion Flange

•Small Pumping Tee

•Slimline Stuffing Box

•Remove Bridal Guard

•Vertical Clearance Above Annulus Opening

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Dual Completion Flange

Top View

Side View

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Hand Packoffs

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Dual Head Configured

&

Pump Is Engaged

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Note that there is not enough room to install a valve on the annulus opening.

These flanges are specifically designed for logging in 4.5” casing. A dual completion flange, if there is such, would not allow enough room in the annulus for tool entry.

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TRAC-III Below Submersible Pump

Y-Tool Assembly

•Well must have 7” casing to accommodate Y-tool.

•Shut-in well & allow fluid to fall below pump

•Fish out plug

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Baby Red

Used to retrieve plug from Y-tool.

Running Plug

Prevents fluids from being circulated by pump.

Y-Tool Accessories For Logging

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TRAC-III Below Submersible Pump

Y-Tool Assembly

•Install running plug on wireline

•Lower TRAC-III Tools & Running Plug to “Y”

•Lower TRAC-III Tools below pump

•Engage pump to seat running plug

•Run logs when well is stable

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Memory PLT•Horizontal wells are the primary application in the Permian Basin.

•No real time feedback allowing procedure modification to maximize information.

•Most wellbore events in producers are not continuous. Your economics must reflect the possibility of multiple runs to accomplish some test objectives.

•Most companies that have access to memory tools do not consider production logging a core business.

•Great weapon, for the right battle!

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Production Logging Tidbits

There are no silver bullets in the production logging industry.

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Production logging for conformance objectives is an investigative process.

It requires the knowledge, experience, and authority to change the logging procedure as needed to define anomalies as they are encountered during the log.

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Avoid the intentional design of tests that rely completely on nuclear based data acquisition. Their maximum radius of investigation is approximately 24 inches from the sensor.

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In production logging, temperature logs are the center of your universe.

They are always correct, although sometimes hard to interpret by themselves.

Use data acquired from others sensors to help you interpret the temperature logs.

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!We Want You On Location!

• Production logging is an investigative process

• Your knowledge of the lease can make the difference between a good survey and a great survey

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Correlation Logs

Logs used to align logging depths to previously run open hole and cased hole logs.

Avoid the LAST LOG SYNDROME. It is generally acceptable for most production logs to be within 2 to 3 feet of measured depth. However, if you are on the 4th or 5th generation of logs, you may be correlating 10’ to 15’ off depth. Always try to use the original open hole logs or the logs used to perforate the well.

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Temperature Logs

Producing temperature logs tend to reflect in wellbore and near wellbore events.

Shut-in temperature logs indicate events outside the wellbore.

You must know the status of the interior of the wellbore before you can interpret shut-in temperatures.

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Capacitance

•Fluid Identification

•Calibrate between water and gas.

•Capacitance VS. Density Tool

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Tracer Velocities

Modified Velocity Profile Measurement

Production fluctuations do not affect the calculations as severely as stationary velocity shots.

Same velocity method is used in flowing wells.

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Tracer Velocities

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Caliper

•Measures internal diameter of wellbore.

•Gives general picture of conditions.

•Improves velocity calculations and profile.

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MergedLog

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Example #1

•Rod pump well in S.E. New Mexico

•Was producing 30 oil, 60 water, and 0 gas.

•New perfs (upper set) added.

•Current production: 200 water, 0 oil, and 0 gas.

•Pump & tubing anchor set at mid perf.

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Example #1 – Customer Designed Procedure

•Set PKR above top perf for PIT and pressure test.

•Well casing held 500 psi above PKR.

•Logs indicate water and porosity in upper set.

•Customer is certain water source is in new zone.

•Run PIT for cement squeeze design.

•Economics will only allow one attempt at fixing the problem.

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Example #1 - Cardinal Recommendation

•POOH & remove PKR.

•Set EOT 100’ - 200’ above top perf.

•Configure surface equipment for an Annulus TRAC-III.

•Determine water source and flow path to wellbore.

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Example #1 - Cardinal Results

Leak in CSG 400’ above top perf producing +300 bpd water. Leak is at a collar and will give up water, but not take water.

Pump removing +/- 200 bpd water to surface.

The new zone dead. It is not giving up or taking fluid.

Productive zone is taking 100 bpd water, crossflow from leaking casing.

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? What If ?

Which zone do you believe would have been squeezed had we followed the original request?

What if water was channeling up from below and into the bottom set of perfs?

What if water was being produced from the new zone? What would be the likely series of events?

End Result: LOST WELL

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Design The Solution(Locate Loss Profile)

Pump-In Tracer or Injection Profile.

A. Stationary Velocity Profile.

B. Intensity Profile

C. Channel Checks

D. Crossflow Checks

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Injection Profiles - Why?• Determine where fluids are going.• Check mechanical integrity of well bore.• Verify conformance to formation porosity.• Locate channels.• Check perforations.• Check fill.• Find scale and build-up.• Discover holes or unreported perforations.

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Injection Profiles - Objectives:

• SAFELY

• Accurate and Quantative

• Detect Mechanical Problems

• Detect Channels

• Minimize Risk to Well

• Perform economically without sacrificing quality.

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Injection Profile Log - Components

• Radioactive Tracers

• Spinner Logs

• Temperature Logs

• Caliper Logs

• Collar Logs

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Injection Profile Log - Logs

• Injecting Temperature Log• Two Radioactive Tracer Logs

– The Intensity Profile – Series of Stationary Velocity Measurements

• Channel Checks• Packer Check• Shut-In Temperature Logs • Cross-Flow Checks • Caliper Log

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Injection Profiles - Preparation: Operator

• Review well records.

• Prepare a wellbore diagram: – Current condition of the well.– Significant past factors and changes. – Well bore equipment (depths, i.d.):

• Casing, liners, tubing, packer(s), plugs, casing shoe(s).

• Downhole control valves (mandrels).

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• Well configuration:– Perforations.

– Open hole intervals.

– Plugged or squeezed zones

– Known thief zones, channels, and other known areas of possible fluid loss should be indicated.

• Well head:– Height.

– Connection required.

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• Unusual conditions:– Remote injection control valves.

– High pressures (above 2000 PSI).

– Safety hazards (hydrogen sulfide).

– Restrictions or modifications to normal procedures.

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• Lease and well data:– Maps with locations, roads, and plants. – Tabulation of injection rates and pressures.– Depth correlation logs (primary log, gamma ray,

collar log).– Previous profile(s).

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• Preparation of the well for survey:– Tubing or tail pipe 50' above the top perforation or shoe.

– Full opening valve.

– Stable rate 48 hours.

– Slick line sinker bar run and T.D. check.

– Rate meter and pressure gauge.

– Install crown valve– Test valves and tree.

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• Information needed at the well site:– Maps with locations, roads, and plants.

– Tabulation of injection rates and pressures.

– Depth correlation logs (primary log, gamma ray, collar log).

– Well diagrams.

– Previous profile(s).

– MSDS as required.

– Well history and recent workovers.

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Logging Tools

•Scintillation Detector•16” to 24” radius of investigation•Geiger Detector is 80% less

•O-ring sealed Ejector Port

•Temperature Tool•0.1 degrees F resolution

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Injection Profiles - Procedures: Logging Procedure

• Logging procedure:– Injecting temperature survey.– Gamma-ray and collar log.

• Correlate to log provided.

– Gamma-ray base log.• (Reduced sensitivity)

– Caliper survey.

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• Logging procedure:– Intensity profile.

• (One “Slug” of radioactive material.)

– Velocity profile.• (Multiple stationary readings.)

– Downward channel check, if applicable.– No Flow check, if applicable.– Upward channel check (shoe or top perf.)

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• Logging procedure:– Packer check.– Tubing drop shots.

• (Verifies meter rate.)

– Check injection rate and record.– Shut-in temperature surveys as required.– Crossflow checks.

• (Necessary to interpret Shut-in Temps.)

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Velocity Profile

• Pi x r2 x h = Volume of a cylinder

• Pro’s: – High resolution of data points– Limited by the spacing from ejector to detector

• Con’s:– Minor plant fluctuations effect calculated rates– I.D. changes have a drastic effect on the

calculated rates

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Calculations and Interpretations:Volumetric Flow Rates

• Volume = PI x Dia^2 / 4 * L

• Volumetric Flow = Vol / Time

Diameter

Length

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Calculations and Interpretations:Application of Volumetric Rates

• Tracer Elapsed Time Runs

• Stationary Velocities

• Spinner Flow Meters

• Tubing Drop Shots

• Crossflow Checks

• Production Log Velocities

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Data Acquisition

A slug of radioactive I-131 isreleased from the ejector andthe travel time is recorded tillarrival at the detector.

The volume of the cylinderand the time of travel is usedto calculate a Barrel Per Dayrate.

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Velocity Shot Example

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Velocity Profile

• Most popular survey method

• Seldom the best

• 5.5” Casing Examples:– 0.25” build up results in a 10.69% error– 1.0” build up results in a 39.41% error

• You must have a caliper log for an accurate stationary velocity survey.

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Calculations and Interpretations:Caliper Log - Required!

In standard 5 1/2” Casing:

• A 1/4” buildup = 11% Error!

• A 1” buildup = 39% Error!

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Injection ProfilesExample Calculations

• I.D. = 4.96”

• Reaction Time = 26.5 sec.

• Tool Spacing = 5 ft.

• Calculated velocity = 0.189 ft/sec

• Calculated volumetric flow = 0.0252 cu.ft./sec

• Flow = 388 BPD

• I.D. = 4.96”

• Reaction Time = 26.5 sec.

• Tool Spacing = 5 ft.

• Calculated velocity = 0.189 ft/sec

• Calculated volumetric flow = 0.0252 cu.ft./sec

• Flow = 388 BPD

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Intensity Profile

• Pro’s:– Not adversely affected by hole size changes– Not affected by plant fluctuations– Gives visual representation of flow patterns

• Con’s:– Less resolution of data points– Limited by velocity of fluid and wireline speeds

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Data Acquisition

One large slug of I-131 is ejectedabove the zone of interest. Multiplegamma ray passes are made upthrough the slug as it travels downhole.

Losses of radioactive material fromthe slug represent the amount of injection lost in those same areas.

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Intensity Profiles

• Resolution of 20’ to 50’ between data points– Velocity of injected fluid– Mechanical limitations of wireline speed

• Resolution enhanced by Velocity Profile

• Usually the best profile method

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Calculations and Interpretations:Intensity Profile

• Tool configuration - one scintillation detector located below the ejector.

• Readings are made versus depth.

• Radioactive material is ejected ("slug") above the perforated or open hole interval.

• Tools lowered approx. 20 ft. below slug, and logged through slug ("drag run").

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• Repeat and catch slug at frequency adequate to determine fluid loss.

• Slug logged at the constant speed.

• Repeat until slug stops moving or is lost to formation.

• Loss calculations from area under curve

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• Quantified loss profile

• Bottom of injection movement (or loss below L.T.D.)

• Possible channeling outside casing

• Possible holes in pipe or other mechanical problems.

• Independent of wellbore diameter changes.

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Intensity Profile(“Drag Run”)

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•Temperature Logs can not distinguish between events occurring inside, or outside the wellbore

•Injection Temperatures show the bottoms of fluid losses and major velocity changes

•Shut-in Temperatures indicate the tops of events and give a relative magnitude of fluid storage

•Injecting and Shut-in logs merging indicate the absolute bottom of fluid movement

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InjectionTemperature

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Cross Flow Checks

Slugs of I-131 are ejected above, between, and below the zones.

Multiple runs are pulled though all the slugs to determine if the is fluidis migrating between zones in the wellbore.

You must know the state of the wellto interpret shut-in temperatures.

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Temperature Logs

Intensity Profile Velocity Profile

Caliper Log

Channel Check

Crossflow Check

No Flow Shot

Log Interpretation

http://www.cardinalsurveys.com

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Mult-Rate Injectivity Test

• Variable conditions / pressures

• Entries (losses) variable

• Accurate placement of chosen solution

• Determine treatment issues / problems

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Example #2

Mechanical Isolation

Customer has flowing gas well in West Texas

Well has been acidized and fraced

Current Production Rate: 10 oil, 600 water, & 6MMcf gas

Test Objective: Reduce water without losing gas production

Production Log Indicates:

Water entry at bottom perfs with channel from below and a minor oil entry

Additional oil entry at mid-perfs.

Major gas entry at top perfs.

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Example #2 - Recommendation

Isolate bottom perfs for mult-rate injection profile test.

Set PKR just below mid-perfs to allow maximum room to monitor any injected fluids channeling up hole toward gas zone.

Establish an envelope of rates and pressures that will keep treatment chemicals in desired intervals.

Rates established in the envelope will allow calculations for the selection of treatment chemicals, catalyst, and other factors needed to place and set a successful treatment.

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ResultsA B C D

A. .25 bpm

B. .50 bpm

C. .75 bpm

Potential Problem

D. 1.0 bpm

Unacceptable

Rate must remain below .5 bpm to keep treatment in target zone.

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? What If ?

•We need more rate. Timing factors on the catalyst for most successful treatment in these situations requires a shorter pump time.

•There is no envelope of rates and pressures to keep the treatment in the desired interval. All rates and pressures reach the good zone.

•WE NEED MORE OPTIONS

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Mechanical-Hydro Isolation

Same well and mechanical configuration

Inject water down tubing and tubing annulus simultaneously

Vary rates and pressures to establish an acceptable envelope

Special Consideration:

How much, if any, water can be injected into primary pay without causing irreversible damage?

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Hydro Isolation - Interface Logging

Forgotten Technology

•One of the first injection profiles ever conceived

•Still the most accurate injection profile known

•Developed for shot hole wells

•Resolution is limited only by pumping and metering equipment at the surface

•More expensive than standard profile services due to time

•Technically the best logging application for pre-treatment, real time monitoring during treatment, and real time monitoring the curing period of conformance treatments.

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Well Configuration

Run blank tubing to just above PBTD

Rig up pump trucks to casing and tubing

Rig up Cardinal Tagmaster to inject I-131 into casing line

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Interface Logging

•Various Rates

•Real Time Feedback

•Position & Stabilize

•Adjust Treatment

•Pre-job

•During Job

•Post Job Containment

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ConclusionsProduction logging can be used to screen wells for conformance treatments by identifying wells with potential for success or ultimate failure.

Production logging gives accurate data that can be used to formulate, monitor, and keep conformance treatments in the intended interval.

Conformance treatments can be greatly enhanced with the use of proper production logging techniques and equipment

DON’T GUESS…… KNOW!

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Example Logs

• Coal Seam Annular Log

• Flowing Production Log

• Spectral Gamma Ray / Multi Iso Tracer

1 cardinal surveys company bringing conformance within reach with proven technology. eliminate the...

Documents

production logging

production logs path

production results

production logsdynamic

marginal production

actual production intervals

inch casing

annulus trac